Divalent brine fluids having improved rheology and multifunctional properties

ABSTRACT

A method of improving rheological properties of a divalent brine based downhole treatment fluid at an elevated temperature comprises adding to the divalent brine based downhole treatment fluid a rheological modifier, which comprises a carboxylic acid ester, or a phosphate ester blended with an ethoxylated glycol, or a combination comprising at least one of the foregoing in an amount effective to improve the rheological properties of the divalent brine based downhole treatment fluid at a temperature of greater than about 200° F. The divalent brine based downhole treatment fluid comprises calcium bromide, calcium chloride, zinc bromide, zinc chloride, or a combination comprising at least one of the foregoing.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a divisional of U.S. application Ser. No. 16/886,961filed May 29, 2020, which is a divisional of U.S. application Ser. No.15/825,480 filed Nov. 29, 2017, which is now U.S. Pat. No. 10,711,174issued Jul. 14, 2020, which claims priority to U.S. Provisional PatentApplication No. 62/429,942, filed Dec. 5, 2016, the disclosure of whichis incorporated by reference herein in its entirety.

BACKGROUND

This disclosure relates to methods of improving the rheology propertiesof divalent brine based fluids. The disclosure also relates to divalentbrine based fluids having improved rheology and multifunctionalproperties and methods of using such fluids.

Divalent brines are mainly used to prepare drill-in fluids. Drill-influids are designed to be essentially non-damaging to the producingformation. Ideally, drill-in fluids can also provide superior holecleaning property, allow easy clean-up, and are cost effective.

In conventional drill-in fluids, organic polymers are often used tocontrol rheological and fluid loss properties. While organic polymersare normally stable in fresh water, they can rapidly degrade in adivalent salt environment resulting in system instability, especially atan elevated temperature. Accordingly, the art would be receptive toalternative additives that are effective to enhance the rheologicalprofile of a divalent brine based fluid at elevated temperatures. Itwould be a further advantage if such additives could also enhance fluidloss control or lubricity of the divalent brine based fluid.

BRIEF DESCRIPTION

A method of improving rheological properties of a divalent brine baseddownhole treatment fluid at an elevated temperature comprises adding tothe divalent brine based downhole treatment fluid a rheologicalmodifier, which comprises a carboxylic acid ester, or a phosphate esterblended with an ethoxylated glycol, or a combination comprising at leastone of the foregoing in an amount effective to improve the rheologicalproperties of the divalent brine based downhole treatment fluid at atemperature of greater than about 200° F. The divalent brine baseddownhole treatment fluid comprises calcium bromide, calcium chloride,zinc bromide, zinc chloride, or a combination comprising at least one ofthe foregoing.

A method of conducting a wellbore operation in a subterranean formationcomprises: employing in the wellbore operation a divalent brine basedtreatment fluid comprising a divalent brine comprising calcium bromide,calcium chloride, zinc bromide, zinc chloride, or a combinationcomprising at least one of the foregoing; and an rheological modifiercomprising a carboxylic acid ester, or a phosphate ester blended with anethoxylated glycol, or a composition comprising at least one of theforegoing.

A divalent brine based downhole treatment fluid comprises about 10 toabout 18 pounds per gallons of a divalent brine comprising calciumbromide, calcium chloride, zinc bromide, zinc chloride, or a combinationcomprising at least one of the foregoing; and about 1 to about 12 poundsof an rheological modifier per barrel of the divalent brine baseddownhole treatment fluid, the rheological modifier comprising acarboxylic acid ester, or a phosphate ester blended with an ethoxylatedglycol, or a composition comprising at least one of the foregoing.

DETAILED DESCRIPTION

It has been found that rheological modifiers described herein impartdesirable properties to a variety of downhole treatment fluids,especially divalent brine based drilling fluids, completion fluids, orservicing fluids. In particular, a carboxylic acid ester or a phosphateester blended with an ethoxylated glycol is effective to enhance therheological properties of the divalent brine based fluids such as yieldpoint and low-shear-rate-viscosity. In a further advantageous feature,the rheological modifiers are effective to enhance the fluid losscontrol and lubricity of the divalent brine based fluids.

The divalent based fluids comprise calcium bromide, calcium chloride,zinc bromide, zinc chloride, or a combination comprising at least one ofthe foregoing. Monovalent brine can optionally be present. Exemplaryfluids contain about 10 to about 18 pounds per gallons of calciumbromide, calcium chloride, or a combination thereof.

The carboxylic acid ester has a formula

wherein R¹ and R² are each independently a C₁₋₂₆ alkyl, C₂₋₂₆ alkenyl,or C₂₋₂₆ alkynyl group. Specifically R¹ is a C₆₋₂₀ alkyl, C₆₋₂₀ alkenyl,or C₆₋₂₀ alkynyl group; and R² is methyl. In another embodiment, R¹ is aC₈₋₁₄ alkyl; and R² is a C₆₋₂₀ alkyl, C₆₋₂₀ alkenyl, or C₆₋₂₀ alkynylgroup. Exemplary carboxylic acid esters have a formula I or II

wherein R¹ and R² are each independently a C₆₋₂₀ alkyl, C₆₋₂₀ alkenyl,or C₆₋₂₀ alkynyl group.

The ethoxylated glycol comprises ethoxylated ethylene glycol,ethoxylated propylene glycol, ethoxylated glycerin, ethoxylatedpolyethylene glycol, ethoxylated polypropylene glycol, or a combinationcomprising at least one of the foregoing.

In an embodiment, the phosphate ester is a hydrocarbyl polyetherphosphate ester optionally comprising one or two hydroxyl groupsdirectly attached to phosphorus.

The rheological modifier can be added to the divalent brine baseddownhole treatment fluid in an amount of about 1 to about 12 pounds orabout 0.5 to about 10 pounds per barrel of the divalent brine baseddownhole treatment fluid (ppb). In exemplary embodiments, when therheological modifier comprises a carboxylic acid ester, the rheologicalmodifier is added in an amount of about 3 to about 8 ppb, and when therheological modifier comprises a phosphate ester blended with anethoxylated glycol, the rheological modifier is added in an amount ofabout 0.5 to about 4 ppb.

The rheological modifiers as disclosed herein are effective to enhancerheological properties particularly yield point,low-shear-rate-viscosity, or a combination comprising at least one ofthe foregoing of the divalent based downhole treatment fluids at atemperature of greater than about 200° F., specifically about 200° F. toabout 300° F. For example, the rheological modifiers can increase theyield point of the fluids for up to about 66%. The addition of therheological modifier further improves the fluid loss control andlubricity of the divalent based downhole treatment fluids.

Known additives typically used in the treatment fluids include but arenot limited to fluid loss control agents, lubricants, pH modifiers, pHstabilizers, viscosifiers, weighting agents, or a combination comprisingat least one of the foregoing. Exemplary pH modifiers include magnesiumoxide, magnesium hydroxide, calcium oxide, calcium hydroxide, zincoxide, zinc hydroxide, and the like. Suitable pH stabilizers includediamines such as ethylene diamine. In an embodiment, the pH stabilizercomprises ethylene diamine and about 1 to about 5 wt. % of apolyimidazoline, based on the total weight of the pH stabilizer.Exemplary weighting agents include calcium carbonate, magnesiumcarbonate, zinc carbonate, calcium magnesium carbonate, manganese tetraoxide and the like.

The divalent brine based downhole fluids can include drilling fluids,completion fluids, or servicing fluids. As used herein, the drillingfluids include drill-in fluids, which are specially designed fordrilling through the reservoir section of a wellbore.

The divalent brine based downhole treatment fluids can have a yieldpoint of about 20 lb/100 ft² to about 40 lb/100 ft² and a plasticviscosity of 26 cP to 38 cP, each determined by hot rolled fluid at 250°F., rheological measurement by OFITE 900 viscometer at 120° F. Thedivalent brine based downhole treatment fluids can also have a lubricitycoefficient of less than 0.13 measured by an OFITE Lubricity Meter. Insome embodiments, the divalent brine based downhole treatment fluidshave a low shear rate viscosity of greater than about 10,000 cP measuredby Brookfield viscometer using spindle S62 at 0.5 rpm. When a diamine pHstabilizer is used, the divalent brine based downhole treatment fluidscan have a pH of greater than about 7.5.

The downhole fluids can be used in various applications. A method ofconducting a wellbore operation in a subterranean formation comprisesemploying the divalent brine based downhole treatment fluid in thewellbore operation. In an embodiment, a method of drilling a wellbore ina subterranean formation comprises circulating a drilling fluid in thesubterranean formation. The circulation path of the drilling fluidtypically extends from the drilling rig down through the drill pipestring to the bit face and back up through the annular space between thedrill pipe string and wellbore face to the wellhead and/or riser,returning to the rig. The drilling fluid performs a number of functionsas it circulates through the wellbore including cooling and lubricatingthe drill bit, removing drill cuttings from the wellbore, aiding insupport of the drill pipe and drill bit, and providing a hydrostatichead to maintain the integrity of the wellbore walls and prevent wellblowouts. The drilling fluid also desirably prevents sloughing andwellbore cave-ins when drilling through water sensitive formations.Drill-in fluids can minimize damage and maximize production of exposedzones. In addition, drill-in fluids can facilitate well completion.

The beneficial effects of using carboxylic acid ester and a blend ofphosphate ester and ethoxylated glycol in downhole treatmentcompositions are further illustrated in the following examples.

Examples

The materials used in the Examples are described in Table 1.

TABLE 1 Component Description Source, Vendor Fluid loss Non Ionic StarchTBC-BRINADD, LLC additive MgO Thermasal B TBC-BRINADD, LLC PH StabilizerDiamine, BAKER HUGHES INC Mil Carb 45 Calcium carbonate BAKER HUGHESINC. Mil Carb Fine Calcium carbonate BAKER HUGHES INC. REV DUST Drillsolid material BAKER HUGHES INC. Phosphate A blend of phosphate esterBAKER HUGHES INC. Ester and ethoxylated glycol Carboxylic Fatty esters,RADIGREEN OLEON N.V. acid ester EME salt product Viscosifier PolysacrideTBC-BRINADD, LLC

Components of drilling fluids were mixed using Multimixer for one hour.The drilling fluids were poured into pressurized aging cells andmaintained at 250° F. for 16 hours hot rolled. Post hot rolledrheological properties were measured by OFITE 900 viscometer inaccordance with API testing procedures. HPHT fluid loss cell was usedfor fluid loss measurement. OFITE Lubricity Meter was used for measuringlubricity coefficient. Fluids were designed with 20 ppb, solidcontamination (REV DUST) and tested at 250° F. Low shear rate viscositymeasured by Brookfield viscometer using spindle S62 at 0.5 rpm. Theformulations of the drilling fluids and their properties are shown inTables 2-6.

TABLE 2 14.4 lb/gal drill-in fluid using CaBr₂ as the base fluidComponents (ppb) 1 2 3 4 5 6 Calcium bromide brine 537 535.50 533.94531.60 531.06 525.07 Fluid loss additive 8 8 8 8 8 8 MgO 5 5 5 5 5 5 PHStabilizer 3 3 3 3 3 3 MIL CARB 45 15 15 15 15 15 15 MIL CARB FINE 20 2020 20 20 20 Phosphate ester — 1 2 3.5 Carboxylic acid ester 3.5 7 FluidProperties After Hot Rolled at 250° F. 600 rpm 91 94 111 115 95 104 300rpm 59 61 73 77 62 70 200 rpm 47 48 58 61 46 53 100 rpm 31 32 41 44 3236  6 rpm 11 11 13 14 10 14  3 rpm 9 9 10 12 8 13 Plastic viscosity, cP32 33 38 38 33 34 Yield point, lb/100 ft² 27 28 35 39 29 36 10 Sec gel,lb/100 ft² 8 8 10 11 8 11 10 Min gel, lb/100 ft² 9 9 11 11 9 12 30 Mingel, lb/100 ft² 9 9 11 11 9 12 HPHT filtrate (mL/30 min) 8 6.4 6.4 6.87.6 7.6 pH 8 8 8 8 7.9 7.74 Lubricity Coefficient 0.16 0.13 0.12 0.120.11 0.10 Low Shear Rate Viscosity, cP 20580 23650 26330

TABLE 3 14.4 lb/gal drill-in fluid using calcium bromide as the basefluid Components (ppb) 7 8 9 Calcium bromide brine 539 536 533.64 Fluidloss additive 6 6 6 MgO 5 5 5 PH Stabilizer 3 3 3 MIL CARB 45 15 15 15MIL CARB FINE 20 20 20 Phosphate ester — 2 3.5 Fluid Properties AfterHot Rolled at 250° F. 600 rpm 63 77 77 300 rpm 39 49 51 200 rpm 30 37 40100 rpm 20 25 28 6 rpm 6 9 9 3 rpm 5 7 8 Plastic viscosity, cP 24 28 26Yield point, lb/100 ft² 15 21 25 10 Sec gel, lb/100 ft² 4 5 7 10 Mingel, lb/100 ft² 5 7 7 30 Min gel, lb/100 ft² 6 8 8 HPHT filtrate (mL/30min) 12 10 10.4 pH 8 8 8 Lubricity Coefficient 0.16 0.13 0.12

TABLE 4 14.4 lb/gal drill-in fluid using calcium bromide as the basefluid with solid contaminations Components (ppb) 1A 1B 1C Calciumbromide brine 537 526.84 531.97 Fluid loss additive 8 8 8 Viscosifier 83.5 MgO 5 5 5 PH Stabilizer 3 3 3 MIL CARB 45 15 15 15 MIL CARB FINE 2020 20 Phosphate ester — 3.5 3.5 REV DUST 20 20 20 Fluid Properties AfterHot Rolled at 250° F. 600 rpm 84 104 91 300 rpm 53 68 61 200 rpm 42 5246 100 rpm 28 35 32 6 rpm 8 12 11 3 rpm 7 10 10 Plastic viscosity, cP 3136 30 Yield point, lb/100 ft² 22 32 31 10 Sec gel, lb/100 ft² 6 8 9 10Min gel, lb/100 ft² 7 9 9 30 Min gel, lb/100 ft² 8 9 9 HPHT filtrate(mL/30 min) 7 7 7.2 pH 8 8 8

TABLE 5 12 lb/gal drill-in fluid using calcium bromide and calciumchloride as the base fluid Components (ppb) 2A 2B CaBr (14.2 ppg) +CaCl₂ brine (11.6 ppg) 465 461.5 Fluid loss additive 8 8 MgO 5 5 PHStabilizer 3 3 MIL CARB 45 15 15 MIL CARB FINE 20 20 Phosphate ester —3.5 Fluid Properties After Hot Rolled at 250° F. 600 rpm 74 97 300 rpm46 62 200 rpm 36 49 100 rpm 24 34 6 rpm 7 12 3 rpm 6 10 Plasticviscosity, cP 28 35 Yield point, lb/100 ft² 18 27 10 Sec gel, lb/100 ft²5 9 10 Min gel, lb/100 ft² 6 10 30 Min gel, lb/100 ft² 7 11 HPHTfiltrate (mL/30 min) 8.2 7.4 HPHT fluid loss, ml/30 min 4.8 3 250°F./500 psi using 55 pH 8.6 8.62 Lubricity Coefficient 0.13 0.10 LowShear Rate Viscosity, cP 14357 15125

TABLE 6 pH enhancement in divalent brine using diamine based pHstabilizer Components (ppb) 3A 3B 3C Calcium bromide brine, 14.2 lb/gal537 534 534 Fluid loss additive 8 8 8 Viscosifier 10 10 10 MgO 5 5 5 PHStabilizer — 3 3 MIL CARB 45 10 10 10 MIL CARB FINE 20 20 20 Phosphateester — 3.5 Carboxylic acid ester 3.5 Fluid Properties After Hot Rolledat 250° F. 600 rpm 93 102 115 300 rpm 60 68 78 200 rpm 48 54 62 100 rpm32 38 44 6 rpm 8 14 17 3 rpm 7 12 15 Plastic viscosity, cP 33 34 37Yield point, lb/100 ft² 27 34 41 10 Sec gel, lb/100 ft² 6 10 14 10 Mingel, lb/100 ft² 6 10 15 30 Min gel, lb/100 ft² 6 11 15 pH 7.4 8.30 8.10

After addition of the rheological modifier to divalent brine basedfluids, significant changes in plastic viscosity, yield point, Low shearrate viscosity, fluid loss, and lubricity of the fluids were observed.

The results indicate that carboxylic acid esters or a phosphate esterblended with ethoxylated glycol are effective to enhance the rheologicaland multifunctional properties of divalent based fluids including thosecontaminated with Rev Dust.

Set forth below are various embodiments of the disclosure.

Embodiment 1. A method of improving rheological properties of a divalentbrine based downhole treatment fluid at an elevated temperature, themethod comprising: adding to the divalent brine based downhole treatmentfluid a rheological modifier comprising a carboxylic acid ester, or aphosphate ester blended with an ethoxylated glycol, or a combinationcomprising at least one of the foregoing in an amount effective toimprove the rheological properties of the divalent brine based downholetreatment fluid at a temperature of greater than about 200° F., thedivalent brine based downhole treatment fluid comprising calciumbromide, calcium chloride, zinc bromide, zinc chloride, or a combinationcomprising at least one of the foregoing.

Embodiment 2. The method of any of the proceeding embodiments, whereinthe carboxylic acid ester has a formula

wherein R¹ and R² are each independently a C₁₋₂₆ alkyl, C₂₋₂₆ alkenyl,or C₂₋₂₆ alkynyl group.

Embodiment 3. The method of claim 2, wherein R¹ is a C₆₋₂₀ alkyl, C₆₋₂₀alkenyl, or C₆₋₂₀ alkynyl group; and R² is methyl. Alternatively, R¹ isa C₈₋₁₄ alkyl; and R² is a C₆₋₂₀ alkyl, C₆₋₂₀ alkenyl, or C₆₋₂₀ alkynylgroup.

Embodiment 4. The method of any of the proceeding embodiments, whereinthe ethoxylated glycol comprises ethoxylated ethylene glycol,ethoxylated propylene glycol, ethoxylated glycerin, ethoxylatedpolyethylene glycol, ethoxylated polypropylene glycol, or a combinationcomprising at least one of the foregoing.

Embodiment 5. The method of any of the proceeding embodiments, whereinthe phosphate ester is a hydrocarbyl polyether phosphate esteroptionally comprising one or two hydroxyl groups directly attached tophosphorus.

Embodiment 6. The method of any of the proceeding embodiments, whereinthe rheological modifier is added to the divalent brine based downholetreatment fluid in an amount of about 1 to about 12 pounds of themodifier per barrel of the divalent brine based downhole treatmentfluid.

Embodiment 7. The method of any of the proceeding embodiments, whereinthe divalent brine based downhole treatment fluid comprises about 10 toabout 18 pounds per gallons of calcium bromide, calcium chloride, or acombination thereof.

Embodiment 8. The method of any of the proceeding embodiments, furthercomprising adding one or more of the following additional component tothe divalent brine based downhole treatment fluid: a fluid loss controlagent; a lubricant, a pH modifier; a pH stabilizer; a viscosifier; or aweighting agent. The pH stabilizer comprises a diamine, and the divalentbrine based downhole treatment fluid with the diamine has a pH ofgreater than about 7.5.

Embodiment 9. The method of any of the proceeding embodiments, whereinthe rheological properties comprise yield point,low-shear-rate-viscosity, or a combination comprising at least one ofthe foregoing.

Embodiment 10. The method of any of the proceeding embodiments, whereinthe addition of the rheological modifier further improves the fluid losscontrol and lubricity of the divalent based downhole treatment fluid.

Embodiment 11. A method of conducting a wellbore operation in asubterranean formation, the method comprising: employing in the wellboreoperation a divalent brine based drilling or servicing fluid comprisinga divalent brine comprising calcium bromide, calcium chloride, zincbromide, zinc chloride, or a combination comprising at least one of theforegoing; and an rheological modifier comprising a carboxylic acidester, or a phosphate ester blended with an ethoxylated glycol, or acomposition comprising at least one of the foregoing.

Embodiment 12. The method of any of the proceeding embodiments, whereinthe carboxylic acid ester has a formula I or II

wherein R¹ and R² are each independently a C₆₋₂₀ alkyl, C₆₋₂₀ alkenyl,or C₆₋₂₀ alkynyl group.

Embodiment 13. The method of any of the proceeding embodiments, whereinthe divalent brine based downhole treatment fluid comprises about 10 toabout 18 pounds per gallons of calcium bromide, calcium chloride, or acombination thereof; and about 1 to about 12 pounds of the modifier perbarrel of the divalent brine based downhole treatment fluid.

Embodiment 14. A divalent brine based downhole treatment fluidcomprising: about 10 to about 18 pounds per gallons of a divalent brinecomprising calcium bromide, calcium chloride, zinc bromide, zincchloride, or a combination comprising at least one of the foregoing; andabout 1 to about 12 pounds of a rheological modifier per barrel of thedivalent brine based downhole treatment fluid, the rheological modifiercomprising a carboxylic acid ester, or a phosphate ester blended with anethoxylated glycol, or a composition comprising at least one of theforegoing.

Embodiment 15. The divalent brine based downhole treatment fluid of anyof the proceeding embodiments, wherein the carboxylic acid ester has aformula I or II

wherein R¹ and R² are each independently a C₆₋₂₀ alkyl, C₆₋₂₀ alkenyl,or C₆₋₂₀ alkynyl group.

Embodiment 16. The divalent brine based downhole treatment fluid of anyof the proceeding embodiments, wherein the ethoxylated glycol comprisesethoxylated ethylene glycol, ethoxylated propylene glycol, ethoxylatedglycerin, ethoxylated polyethylene glycol, ethoxylated polypropyleneglycol, or a combination comprising at least one of the foregoing; andthe phosphate ester is a hydrocarbyl polyether phosphate esteroptionally comprising one or two hydroxyl groups directly attached tophosphorus.

Embodiment 17. The divalent brine based downhole treatment fluid of anyof the proceeding embodiments further comprising a diamine based pHstabilizer, and the fluid has a pH of greater than about 7.5.

Embodiment 18. The divalent brine based downhole treatment fluid of anyof the proceeding embodiments, wherein the fluid has a yield point ofabout 20 lb/100 ft² to about 40 lb/100 ft² and a plastic viscosity of 26cP to 38 cP, each determined by OFITE 900 viscometer at 120° F., afterhot rolled fluid at 250° F.

Embodiment 19. The divalent brine based downhole treatment fluid of anyof the proceeding embodiments, wherein the fluid has a low shear rateviscosity of greater than 10,000 cP measured by Brookfield viscometerusing spindle S62 at 0.5 rpm.

Embodiment 20. The divalent brine based downhole treatment fluid of anyof the proceeding embodiments, wherein the fluid has a lubricitycoefficient of less than 0.13 measured by an OFITE Lubricity Meter.

All ranges disclosed herein are inclusive of the endpoints, and theendpoints are independently combinable with each other. As used herein,“combination” is inclusive of blends, mixtures, alloys, reactionproducts, and the like. All references are incorporated herein byreference in their entirety.

The use of the terms “a” and “an” and “the” and similar referents in thecontext of describing the invention (especially in the context of thefollowing claims) are to be construed to cover both the singular and theplural, unless otherwise indicated herein or clearly contradicted bycontext. “Or” means “and/or.” The modifier “about” used in connectionwith a quantity is inclusive of the stated value and has the meaningdictated by the context (e.g., it includes the degree of errorassociated with measurement of the particular quantity).

1. A divalent brine based downhole treatment fluid comprising: about 10to about 18 pounds per gallons of a divalent brine comprising calciumbromide, calcium chloride, zinc bromide, zinc chloride, or a combinationcomprising at least one of the foregoing; a rheological modifier presentin an amount effective to improve the rheological properties of thedivalent brine based downhole treatment fluid at a temperature ofgreater than about 200° F., the rheological modifier comprising aphosphate ester blended with an ethoxylated glycol, and the divalentbrine based downhole treatment fluid comprising about 1 to about 12pounds of the rheological modifier per barrel of the divalent brinebased downhole treatment fluid; and a pH stabilizer comprising adiamine.
 2. The divalent brine based downhole treatment fluid of claim1, wherein the ethoxylated glycol comprises ethoxylated ethylene glycol,ethoxylated propylene glycol, ethoxylated glycerin, ethoxylatedpolyethylene glycol, ethoxylated polypropylene glycol, or a combinationcomprising at least one of the foregoing.
 3. The divalent brine baseddownhole treatment fluid of claim 1, wherein the phosphate ester is ahydrocarbyl polyether phosphate ester optionally comprising one or twohydroxyl groups directly attached to phosphorus.
 4. The divalent brinebased downhole treatment fluid of claim 1, wherein the fluid has a pH ofgreater than about 7.5.
 5. The divalent brine based downhole treatmentfluid of claim 1, wherein the divalent brine based downhole treatmentfluid comprises about 0.5 to about 4 pounds of the rheological modifierper barrel of the divalent brine based downhole treatment fluid.
 6. Thedivalent brine based downhole treatment fluid of claim 1, wherein thedivalent brine based downhole treatment fluid comprises about 10 toabout 18 pounds per gallons of calcium bromide, calcium chloride, or acombination thereof.
 7. The divalent brine based downhole treatmentfluid of claim 1, further comprising one or more of the followingadditional component: a fluid loss control agent; a lubricant; aviscosifier; a pH modifier; or a weighting agent.
 8. The divalent brinebased downhole treatment fluid of claim 1, wherein the divalent brinebased downhole treatment fluid is a drilling fluid, a completion fluid,or a servicing fluid.
 9. The divalent brine based downhole treatmentfluid of claim 1, wherein the rheological properties comprise yieldpoint, low-shear-rate-viscosity, or a combination comprising at leastone of the foregoing.
 10. The divalent brine based downhole treatmentfluid of claim 1, wherein the pH stabilizer comprises ethylene diamineand about 1 to about 5 wt. % of a polyimidazoline, based on the totalweight of the pH stabilizer.
 11. The divalent brine based downholetreatment fluid of claim 1, wherein the fluid has a yield point of about20 lb/100 ft² to about 40 lb/100 ft² and a plastic viscosity of 26 cP to38 cP, each determined by OFITE 900 viscometer at 120° F., after hotrolled the fluid at 250° F.
 12. The divalent brine based downholetreatment fluid of claim 1, having a low shear rate viscosity of greaterthan 10,000 cP measured by Brookfield viscometer using spindle S62 at0.5 rpm.
 13. The divalent brine based downhole treatment fluid of claim1, having a lubricity coefficient of less than 0.13 measured by an OFITELubricity Meter.
 14. A method of conducting a wellbore operation in asubterranean formation, the method comprising: employing in the wellboreoperation a divalent brine based downhole treatment fluid of claim 1.15. The method of claim 1, wherein the wellbore operation is a drillingoperation, and the method comprises circulating the divalent brine baseddownhole treatment fluid in the subterranean formation.